[go: up one dir, main page]

EP4298315B1 - Outils laser de fonds de puits et procédés - Google Patents

Outils laser de fonds de puits et procédés Download PDF

Info

Publication number
EP4298315B1
EP4298315B1 EP22709894.4A EP22709894A EP4298315B1 EP 4298315 B1 EP4298315 B1 EP 4298315B1 EP 22709894 A EP22709894 A EP 22709894A EP 4298315 B1 EP4298315 B1 EP 4298315B1
Authority
EP
European Patent Office
Prior art keywords
lens
ring
laser beam
downhole equipment
tool
Prior art date
Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
Active
Application number
EP22709894.4A
Other languages
German (de)
English (en)
Other versions
EP4298315A1 (fr
Inventor
Sameeh Issa Batarseh
Damian Pablo SAN ROMAN ALERIGI
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
Saudi Arabian Oil Co
Original Assignee
Saudi Arabian Oil Co
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Saudi Arabian Oil Co filed Critical Saudi Arabian Oil Co
Publication of EP4298315A1 publication Critical patent/EP4298315A1/fr
Application granted granted Critical
Publication of EP4298315B1 publication Critical patent/EP4298315B1/fr
Active legal-status Critical Current
Anticipated expiration legal-status Critical

Links

Images

Classifications

    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B31/00—Fishing for or freeing objects in boreholes or wells
    • E21B31/002—Destroying the objects to be fished, e.g. by explosive means
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B31/00—Fishing for or freeing objects in boreholes or wells
    • E21B31/12—Grappling tools, e.g. tongs or grabs
    • E21B31/16—Grappling tools, e.g. tongs or grabs combined with cutting or destroying means
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B31/00—Fishing for or freeing objects in boreholes or wells
    • E21B31/12—Grappling tools, e.g. tongs or grabs
    • E21B31/18—Grappling tools, e.g. tongs or grabs gripping externally, e.g. overshot

Definitions

  • Hydrocarbon fluids are often found in hydrocarbon reservoirs located in porous rock formations below the earth's surface. Hydrocarbon wells may be drilled to extract the hydrocarbon fluids from the hydrocarbon reservoirs. Hydrocarbon wells may be drilled by running a drill string, comprised of a drill bit and a bottom hole assembly, into a wellbore to break the rock and extend the depth of the wellbore. A fluid may be pumped through the drill bit to help cool and lubricate the drill bit, provide bottom hole pressure, and carry cuttings to the surface. In drilling operations, the drill string may become stuck. A stuck drill string, commonly called “stuck pipe", occurs when the drill string cannot be moved up or down the wellbore without excessive force being applied. Often, when trying to free the stuck pipe, a portion of the drill string may be broken off and left in the wellbore. This portion of the drill string is called a fish, and a fishing operation may be needed to retrieve the fish from the wellbore.
  • a stuck drill string commonly called "stuck pipe”
  • Jars are mechanical devices that deliver an impact load to the portion of the drill string that is stuck.
  • Overshot tools commonly run in tandem with a crude drilling surface that allows the overshot tool to be lightly drilled over the stuck pipe, may grab onto the fish in order to pull the fish from the wellbore.
  • Other examples of tools for removing objects from a wellbore, some of them using a laser system, are described in patent documents US 2014/0090846 A1 , WO 2014/031116 A1 and US 9926758 B1 .
  • a laser system according to the invention for freeing downhole equipment and a method to operate the system are defined by the appended independent claims. Specific embodiments are defined by the dependent claims.
  • Such a laser system includes a laser tool having an inner diameter larger than an outer diameter of the downhole equipment and a means for generating a ring-shaped collimated laser beam.
  • the laser system further includes a work string with the inner diameter larger than the outer diameter of the downhole equipment. The laser tool is installed on the work string and the work string is lowered around the downhole equipment.
  • the laser tool Upon lowering the work string to a position in which the laser tool is located proximate to an obstruction of the downhole equipment, the laser tool emits the ring-shaped collimated laser beam so as to clear out an annulus space between the downhole equipment and a wellbore wall in order to free the downhole equipment.
  • the method for operating the laser system includes installing a laser tool, the laser tool having means for generating a ring-shaped collimated laser beam, onto a work string.
  • the laser tool and the work string have an inner diameter larger than an outer diameter of the downhole equipment.
  • the work string and the laser tool are lowered over the downhole equipment to a position located proximate to an obstruction of the downhole equipment.
  • the ring-shaped collimated laser beam is generated and emitted into an annulus between the downhole equipment and a wellbore wall so as to clear out the obstruction, and the work string and the laser tool are pulled out of the wellbore.
  • ordinal numbers e.g., first, second, third, etc.
  • an element i.e., any noun in the application.
  • the use of ordinal numbers is not to imply or create any particular ordering of the elements nor to limit any element to being only a single element unless expressly disclosed, such as using the terms "before”, “after”, “single”, and other such terminology. Rather, the use of ordinal numbers is to distinguish between the elements.
  • a first element is distinct from a second element, and the first element may encompass more than one element and succeed (or precede) the second element in an ordering of elements.
  • FIG. 1 illustrates an exemplary well site (100).
  • well sites may be configured in a myriad of ways. Therefore, well site (100) is not intended to be limiting with respect to the particular configuration of the drilling equipment.
  • the well site (100) is depicted as being on land. In other examples, the well site (100) may be offshore, and drilling may be carried out with or without use of a marine riser.
  • a drilling operation at well site (100) may include drilling a wellbore (102) into a subsurface including various formations (104, 106). For the purpose of drilling a new section of wellbore (102), a drill string (108) is suspended within the wellbore (102).
  • the drill string (108) may include one or more drill pipes (109) connected to form conduit and a bottom hole assembly (BHA) (110) disposed at the distal end of the conduit.
  • the BHA (110) may include a drill bit (112) to cut into the subsurface rock.
  • the BHA (110) may include measurement tools, such as a measurement-while-drilling (MWD) tool (114) and logging-while-drilling (LWD) tool 116.
  • Measurement tools (114, 116) may include sensors and hardware to measure downhole drilling parameters, and these measurements may be transmitted to the surface using any suitable telemetry system known in the art.
  • the BHA (110) and the drill string (108) may include other drilling tools known in the art but not specifically shown.
  • the drill string (108) may be suspended in wellbore (102) by a derrick (118).
  • a crown block (120) may be mounted at the top of the derrick (118), and a traveling block (122) may hang down from the crown block (120) by means of a cable or drilling line (124).
  • One end of the cable (124) may be connected to a drawworks (126), which is a reeling device that can be used to adjust the length of the cable (124) so that the traveling block (122) may move up or down the derrick (118).
  • the traveling block (122) may include a hook (128) on which a top drive (130) is supported.
  • the top drive (130) is coupled to the top of the drill string (108) and is operable to rotate the drill string (108).
  • the drill string (108) may be rotated by means of a rotary table (not shown) on the drilling floor (131).
  • Drilling fluid (commonly called mud) may be stored in a mud pit (132), and at least one pump (134) may pump the mud from the mud pit (132) into the drill string (108).
  • the mud may flow into the drill string (108) through appropriate flow paths in the top drive (130) (or a rotary swivel if a rotary table is used instead of a top drive to rotate the drill string (108)).
  • a system (200) may be disposed at or communicate with the well site (100).
  • the system (200) may control at least a portion of a drilling operation at the well site (100) by providing controls to various components of the drilling operation.
  • system (200) may receive data from one or more sensors (160) arranged to measure controllable parameters of the drilling operation.
  • sensors (160) may be arranged to measure WOB (weight on bit), RPM (drill string rotational speed), GPM (flow rate of the mud pumps), and ROP (rate of penetration of the drilling operation).
  • Sensors (160) may be positioned to measure parameter(s) related to the rotation of the drill string (108), parameter(s) related to travel of the traveling block (122), which may be used to determine ROP of the drilling operation, and parameter(s) related to flow rate of the pump (134).
  • sensors (160) are shown on drill string (108) and proximate mud pump (134). The illustrated locations of sensors (160) are not intended to be limiting, and sensors (160) could be disposed wherever drilling parameters need to be measured. Moreover, there may be many more sensors (160) than shown in FIG. 1 to measure various other parameters of the drilling operation. Each sensor (160) may be configured to measure a desired physical stimulus.
  • the drill string (108) is rotated relative to the wellbore (102), and weight is applied to the drill bit (112) to enable the drill bit (112) to break rock as the drill string (108) is rotated.
  • the drill bit (112) may be rotated independently with a drilling motor.
  • the drill bit (112) may be rotated using a combination of the drilling motor and the top drive (130) (or a rotary swivel if a rotary table is used instead of a top drive to rotate the drill string (108)). While cutting rock with the drill bit (112), mud is pumped into the drill string (108).
  • the mud flows down the drill string (108) and exits into the bottom of the wellbore (102) through nozzles in the drill bit (112).
  • the mud in the wellbore (102) then flows back up to the surface in an annular space between the drill string (108) and the wellbore (102) with entrained cuttings.
  • the mud with the cuttings is returned to the pit (132) to be circulated back again into the drill string (108).
  • the cuttings are removed from the mud, and the mud is reconditioned as necessary, before pumping the mud again into the drill string (108).
  • the drilling operation may be controlled by the system (200).
  • FIG. 2 depicts, in one or more embodiments, a proposed configuration of a laser tool (202) apparatus comprising a laser head housing (204), a fiber optic cable (206), a first lens (208), a second lens (210), and a cover lens (212).
  • the laser head housing (204) houses and protects the fiber optic cable (206), the first lens (208), the second lens (210), and the cover lens (212).
  • the cover lens (212) protects the first lens (208) and the second lens (210) from splatter and debris during the laser process.
  • the fiber optic cable (206) produces a raw laser beam (214) that enters into the first lens (208) which focuses and controls the shape of the beam.
  • the raw laser beam (214) enters the second lens (210) to produce a ring-shaped collimated laser beam (216).
  • the first lens (208) and the second lens (210) may be conic lenses of a particular internal angle (218), diameter (220), edge thickness (222), and center thickness (224).
  • the first lens (208) and the second lens (210) have a particular aspect ratio which is the ratio of the lenses' (208, 210) center thickness (224) to diameter (220).
  • the aspect ratio and internal angle (218) of the first lens (208) and the second lens (210) determine the inner diameter (226) of the ring-shaped collimated laser beam (216), the outer diameter (228) of the ring-shaped collimated laser beam (216), and the eccentricity of the ring-shaped collimated laser beam (216).
  • the eccentricity of the ring-shaped collimated laser beam (216) may be a circle, parabola, or elliptical transversal beam profile.
  • the diameter (220) of the lenses (208, 210) should be a value between 1.1 times the outer diameter (228) of the ring-shaped collimated laser beam (216) and 1.9 times the inner diameter of the laser tool (202).
  • the internal angle (218) of the first lens (208) and the second lens (210) must be the same.
  • the lenses (208, 210) may be a reflection, such as depicted in FIG. 2 , the lenses (208, 210) may also be reflected in the opposite direction from what is depicted.
  • CT ET + D 2 cot ⁇ 2
  • the thickness of the ring-shaped collimated laser beam (216) is a lateral distance between the outer diameter (228) and the inner diameter (226) of the ring-shaped collimated laser beam (216).
  • BT R beam 1 ⁇ n 2 sin 2 ⁇ cos ⁇ n sin 2 ⁇ + cos ⁇ 1 ⁇ n 2 sin 2 ⁇
  • an aspheric or spherical lens may be positioned between the first lens (208) and the second lens (210) or after the second lens (210) to reduce the thickness of the ring-shaped collimated laser beam (216).
  • the aspheric or spherical lens is positioned between the first lens (208) and the second lens (210)
  • the ring-shaped collimated laser beam is reduced up to the diffraction limit of the aspheric or spherical lens.
  • the aspheric or spherical lens is positioned after the second lens (210), the ring-shaped collimated laser beam is thinned and focused and is not relied on the diffraction limit of the aspheric or spherical lens.
  • the second lens (210) may be transformed into a switchable mirror or glass using electro-optical glazing, electrochromic materials, or non-Hermitian materials to yield perfect transparency or reflectance.
  • a conic switchable mirror/glass with flat surfaces may also be placed after the second lens (210) to reflect the ring-shaped collimated laser beam (216) in an outward direction radially away from the laser tool (202), however the energy density of the ring-shaped collimated laser beam (216) would decrease.
  • a conic switchable mirror/glass with a hyperbolic surface would keep a higher energy density while still reflecting the ring-shaped collimated laser beam (216) in an outward direction radially away from the laser tool (202).
  • ring-shaped collimated laser beam (216)
  • Any suitable method of producing a ring-shaped collimated laser beam such as using static/dynamic refractive/diffractive elements, transformation optical devices, or micro/macro patterned windows/mirrors, may be used without departing from the scope of this disclosure herein.
  • FIG. 3 depicts the laser tool (302) deployed in a wellbore (336) to free stuck pipe.
  • the downhole equipment (330) is stuck at a plurality of stuck points (334).
  • the downhole equipment (330) may be a drill string (108) as depicted in FIG. 3 , or the downhole equipment (330) may be any equipment that may be used for any operation performed in a wellbore (336) such as a completions string, a production string, casing, or any type of tubular or tool.
  • the stuck points (334) are depicted as being located around the bottom hole assembly (110) of a drill string (108), however, the stuck points (334) may occur at any location along the downhole equipment (330).
  • FIG. 1 the stuck points
  • the stuck points (334) may be caused by material (342).
  • the material (342) that may be causing the stuck points (334) may comprise cuttings, wall cavings, or tools that have been broken or lost in the wellbore (336).
  • the stuck points (334) may be cause by irregularities of the wellbore wall (338).
  • Wellbore wall (338) irregularities may be an inconsistent inner diameter or portions of the wellbore wall (338) protruding or jutting into the wellbore (336).
  • the laser tool (302) is run in the wellbore (336) by a work string (332).
  • the inner diameter of the work string (332) and laser tool (302) is larger than the outer diameter of the downhole equipment (330) such that the work string (332) and laser tool (302) are lowered around the downhole equipment (330).
  • the laser tool (302) emits the ring-shaped collimated laser beam (316) to clear material (342), or wellbore wall (338) irregularities, from the annulus (340) space between the downhole equipment (330) and the wellbore wall (338) in order to remove the obstructions and free the downhole equipment (330).
  • the inner diameter (226) of the ring-shaped collimated laser beam (316) is larger than the outer diameter of the downhole equipment (330) such that the ring-shaped collimated laser beam (316) may run parallel to the downhole equipment (330) without damaging the downhole equipment (330).
  • FIG. 4 depicts the laser tool (402) deployed in a wellbore (436) to free stuck downhole equipment (430).
  • the downhole equipment (430) is stuck at a plurality of stuck points (434) and the downhole equipment (430) has been broken or twisted off.
  • the laser tool (402) is run in the wellbore (436) by an overshot tool (446).
  • Overshot tools (446) are used to retrieve a fish from a wellbore (436) and are commonly configured with a top sub (448), a bowl (450), a grapple (452), and a packer (454).
  • the top sub (448) is the uppermost component of the overshot tool (446) and is equipped with a box connection to connect to the pipe (444) used to trip the overshot tool (446) into the wellbore (436).
  • the bowl (450) is the major working component of the overshot tool (446).
  • the inside diameter of the bowl (450) features a threaded section that conforms to the exterior threads of the grapple (452).
  • the grapple (452) is the gripping mechanism of the overshot tool (446) and the grapple (452) may be a basket grapple (452) or a spiral grapple (452).
  • a basket grapple (452) is a slotted, expandable cylinder with a wickered interior to engage the fish. The basket grapple (452) engages the fish by passing over the fish, and, when a pull load is applied, the grapple (452) bites into the fish using the wickers.
  • a spiral grapple (452) is similar to a left hand coil spring. Its outside diameter has a taper form which mates with the left hand scroll taper in the bowl (450). Left hand helical serrations in the bore provide the catch wickers.
  • the spiral grapple (452) engages the fish by rotating over the fish in a specific direction, and, when a pull load is applied, the grapple (452) bites into the fish to form a grip that may pull the fish from the wellbore (436).
  • a type A packer (454) is used with the spiral grapple (452) and seals against the inside of the bowl (450) and around the outside of the fish.
  • a mill control packer (454) is used with the basket grapple (452) and is used to provide a positive seal around the fish and remove small burrs.
  • a burr is a raised edge or small piece of material that remains attached to a work piece after a modification process.
  • the overshot tool (446) and laser tool (402) may trip into the wellbore (436) by passing over the downhole equipment (430).
  • the laser tool (402) may emit the ring-shaped collimated laser beam (416) to clear out the annulus (440), between the downhole equipment (430) and the wellbore wall (436), of material (442) to remove the obstructions.
  • the overshot tool (446) may be engaged and the fish may be pulled out of the wellbore (436).
  • FIG. 5 depicts the laser tool (502) configured to cut downhole equipment (530).
  • the laser tool (502) is run into the wellbore (536) by a work string (532).
  • the downhole equipment (530) is stuck in the wellbore (536) at a number of stuck points (534).
  • the material (542) in the wellbore (536) has packed off the downhole equipment (530) to create the stuck points (534).
  • the work string (532) and laser tool (502) may be tripped into the wellbore (536) by passing over and encompassing the downhole equipment (530).
  • the laser tool (502) may emit a cone ring-shaped collimated laser beam (517) and direct the laser beam (516) onto the downhole equipment (530).
  • the cone ring-shaped collimated laser beam (517) may cut the downhole equipment (530) above the stuck points (534) in order to pull the detached portion of the downhole equipment (530) out of the wellbore (536).
  • the remaining downhole equipment (530), or the fish may be freed by conventional fishing methods or by running the laser system of FIG. 3 or 4 .
  • the fish may be left in the wellbore (536) and the well may be abandoned.
  • the wellbore (536) may be plugged and the drilling operation may produce a sidetracked well from the original wellbore (536).
  • the laser system as depicted in FIG. 5 , may be run into the wellbore (536) by the overshot tool (446) introduced in FIG. 4 .
  • the laser system of FIG. 5 may run the ring-shaped collimated laser beam (216, 316, 416) laser tool in tandem with the laser tool (502), depicted in FIG. 5 , so the annulus (540), between the downhole equipment (530) and wellbore wall (538), may be cleared of materials (542) prior to or after the detached portion of the downhole equipment (530) has been removed from the wellbore (536).
  • FIG. 6 depicts, in accordance with one or more embodiments, a flow chart for utilizing a laser system. While the various blocks in FIG. 6 are presented and described sequentially, one of ordinary skill in the art will appreciate that some or all of the blocks may be executed in different orders, may be combined or omitted, and some or all of the blocks may be executed in parallel. Furthermore, the blocks may be performed actively or passively.
  • a laser tool (202, 302, 402, 502) configured with a means for generating a ring-shaped collimated laser beam (216, 316, 416), is installed in a work string (332, 532) (S656).
  • the work string (332, 532) may be comprised of any pipe (444) that can be used in conditions experienced downhole, such as drill pipe (444).
  • the means for generating a ring-shaped collimated laser beam (216, 316, 416) may comprise a method that uses a fiber optic cable (206), a first conic lens (208), and a second conic lens (210).
  • the fiber optic cable (206) emits a raw laser beam (214) into the first conic lens (208) which focuses and controls the shape of the beam.
  • the diverging laser beam enters the second lens (210) to produce the ring-shaped collimated laser beam (216, 316, 416).
  • the inner diameter (226), outer diameter (228), and eccentricity of the ring-shaped collimated laser (216, 316, 416) may be changed depending on the internal angle (218) and aspect ratio of the conic lenses (210, 212). Any means of producing a ring-shaped collimated laser beam (216, 316, 416) may be used herein without departing from the scope of this disclosure.
  • the collimated ring shaped laser beam (216, 316, 416) has an inner diameter (226) larger than the outer diameter of the downhole equipment (330, 430, 530), so, when the ring-shaped collimated laser beam (216, 316, 416) is emitted, the downhole equipment (330, 430, 530) is unharmed.
  • the work string (332, 532) and the laser tool (202, 302, 402, 502) have inner diameters larger than the outer diameter of the downhole equipment (330, 430, 530) such that the work string (332, 532) and laser tool (202, 302, 402, 502) are lowered over the downhole equipment (330, 430, 530), using the top drive (130), to a depth of a stuck point (334, 434) within the wellbore (336, 436, 536) (S658).
  • the ring-shaped collimated laser beam (216, 316, 416) is generated by the laser tool (202, 302, 402, 502) and emitted into an annulus (340, 440, 540) between the downhole equipment (330, 430, 530) and the wellbore wall (338, 438, 538) (S660).
  • the ring-shaped collimated laser beam (216, 316, 416) drills out the annulus (340, 440, 540) and clears the materials (342, 442, 542) that are causing the stuck points (334, 434) in order to free the downhole equipment (330, 430, 530) (S662).
  • the material (342, 442, 542) that may be causing the stuck points (334, 434) may include cuttings, wall cavings, or tools that have been broken or lost in the wellbore (336, 436, 536).
  • the work string (332, 532) and the laser tool (202, 302, 402, 502) are pulled out of the wellbore (336, 436, 536) using the top drive (130) (S664).
  • wellbore (336, 436, 536) operations such as drilling, workover, or completion operations may continue (S668).
  • other fishing operations may be performed; the wellbore (336, 436, 536) may be plugged and abandoned; or the fish may be left downhole and the wellbore (336, 436, 536) may be sidetracked.
  • FIG. 7 depicts, in accordance with one or more embodiments, a flow chart for utilizing a laser system. While the various blocks in FIG. 7 are presented and described sequentially, one of ordinary skill in the art will appreciate that some or all of the blocks may be executed in different orders, may be combined or omitted, and some or all of the blocks may be executed in parallel. Furthermore, the blocks may be performed actively or passively.
  • a laser tool (202, 302, 402, 502), configured with a means of generating a ring-shaped collimated laser beam (216, 316, 416) is installed into an overshot tool (446) (S770).
  • the means for generating a ring-shaped collimated laser beam (216, 316, 416) may comprise a method that uses a fiber optic cable (206), a first conic lens (208), and a second conic lens (210).
  • the fiber optic cable (206) emits a raw laser beam (214) into the first conic lens (208) which focuses and controls the shape of the beam.
  • the diverging laser beam enters the second lens (210) to produce the ring-shaped collimated laser beam (216, 316, 416).
  • the inner diameter (226), outer diameter (228), and eccentricity of the ring-shaped collimated laser (216, 316, 416) may be changed depending on the internal angle (218) and aspect ratio of the conic lenses (210, 212). Any means of producing a ring-shaped collimated laser beam (216, 316, 416) may be used herein without departing from the scope of this disclosure.
  • the collimated ring shaped laser beam (216, 316, 416) has an inner diameter (226) larger than the outer diameter of the downhole equipment (330, 430, 530), so, when the ring-shaped collimated laser beam (216, 316, 416) is emitted, the downhole equipment (330, 430, 530) is unharmed.
  • the overshot tool (446) is a tool that may latch on to a fish and pull the fish out of the wellbore (336, 436, 536).
  • the overshot tool (446) may be comprised of a top sub (448), a bowl (450), a grapple (452), and a packer (454).
  • the overshot tool (446) and the laser tool (202, 302, 402, 502) are lowered into a wellbore (336, 436, 536), by a top drive (130), to meet a broken or twisted off piece of downhole equipment (330, 430, 530) that was left in the wellbore (336, 436, 536) (S772).
  • the overshot tool (446) and the laser tool (202, 302, 402, 502) are lowered around the downhole equipment (330, 430, 530), and the ring-shaped collimated laser beam (216, 316, 416) is generated by the laser tool (202, 302, 402, 502) and emitted into an annulus (340, 440, 540) between the downhole equipment (330, 430, 530) and a wellbore wall (338, 438, 538) (S774).
  • the ring-shaped collimated laser beam (216, 316, 416) clears the annulus (340, 440, 540) of materials (342, 442, 542) that are packing off the downhole equipment (330, 430, 530) and causing the stuck points (334, 434) (S776).
  • the overshot tool (446) is engaged by providing an upward force by the top drive (130).
  • the grapple (452) latches on to the downhole equipment (330, 430, 530) (S778) and the downhole equipment (330, 430, 530) is pulled out of the wellbore (336, 436, 536) (S780).
  • wellbore (336, 436, 536) operations such as drilling, workover, or completion operations may continue (S782).
  • other fishing operations may be performed; the wellbore (336, 436, 536) may be plugged and abandoned; or the fish may be left downhole and the wellbore (336, 436, 536) may be sidetracked.
  • FIG. 8 depicts, in accordance with one or more embodiments, a flow chart for utilizing a laser system. While the various blocks in FIG. 8 are presented and described sequentially, one of ordinary skill in the art will appreciate that some or all of the blocks may be executed in different orders, may be combined or omitted, and some or all of the blocks may be executed in parallel. Furthermore, the blocks may be performed actively or passively.
  • a laser tool (202, 302, 402, 502), configured with a means of generating a ring-shaped collimated laser beam (216, 316, 416) and a cone ring shaped collimated laser beam (517) is installed in an overshot tool (446) (S884).
  • the means for generating a ring-shaped collimated laser beam (216, 316, 416) may comprise a method that uses a fiber optic cable (206), a first conic lens (208), and a second conic lens (210).
  • the fiber optic cable (206) emits a raw laser beam (214) into the first conic lens (208) which focuses and controls the shape of the beam.
  • the diverging laser beam enters the second lens (210) to produce the ring-shaped collimated laser beam (216, 316, 416).
  • the inner diameter (226), outer diameter (228), and eccentricity of the ring-shaped collimated laser (216, 316, 416) may be changed depending on the internal angle (218) and aspect ratio of the conic lenses (210, 212). Any means of producing a ring-shaped collimated laser beam (216, 316, 416) may be used herein without departing from the scope of this disclosure.
  • the ring-shaped collimated laser beam (216, 316, 416) has an inner diameter (226) larger than the outer diameter of the downhole equipment (330, 430, 530), so, when the ring-shaped collimated laser beam (216, 316, 416) is emitted, the downhole equipment (330, 430, 530) is unharmed.
  • the cone ring-shaped collimated laser beam (517) has an inner diameter and an outer diameter that decrease to a size smaller than the downhole equipment (330, 430, 530) such that the cone ring-shaped collimated laser beam (517) may cut the downhole equipment (330, 430, 530).
  • the overshot tool (446) is a tool that may latch on to a fish and pull the fish out of the wellbore (336, 436, 536).
  • the overshot tool (446) may be comprised of a top sub (448), a bowl (450), a grapple (452), and a packer (454).
  • the overshot tool (446) and the laser tool (202, 302, 402, 502) are lowered into a wellbore (336, 436, 536), by a top drive (130), over downhole equipment (330, 430, 530) to a depth of a stuck point (334, 434) within the wellbore (336, 436, 536) (S886).
  • the cone ring-shaped collimated laser beam (517) is generated by the laser tool (202, 302, 402, 502) and emitted to cut the downhole equipment (330, 430, 530) at a point above the stuck points (334, 434) (S888).
  • Slips are placed around the overshot tool (446), on the drilling floor (131), to hold the weight of the overshot tool (446) (S890).
  • the top drive (130) is screwed into the top stand of the downhole equipment (330, 430, 530) to pull the detached downhole equipment (330, 430, 530) out of the wellbore (336, 436, 536) (S892). Screw the top drive (130) back into the overshot tool (446) and remove the slips (S893).
  • wellbore (336, 436, 536) operations such as drilling, workover, or completion operations may continue (S899).
  • other fishing operations may be performed; the wellbore (336, 436, 536) may be plugged and abandoned; or the fish may be left downhole and the wellbore (336, 436, 536) may be sidetracked.

Landscapes

  • Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Geology (AREA)
  • Mining & Mineral Resources (AREA)
  • Marine Sciences & Fisheries (AREA)
  • Physics & Mathematics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Laser Beam Processing (AREA)

Claims (12)

  1. Système laser pour libérer un équipement de fond de puits (330, 430, 530) d'un puits de forage (102, 336, 436, 536), caractérisé en ce qu'il comprend :
    un outil laser (202, 302, 402, 502), dont le diamètre intérieur est supérieur au diamètre extérieur de l'équipement de fond de puits, l'outil laser comprenant des moyens pour générer un faisceau laser collimaté en forme d'anneau (216, 316, 416, 517) ; et
    une colonne de travail (332, 532) dont le diamètre intérieur est supérieur au diamètre extérieur de l'équipement de fond de puits,
    dans lequel l'outil laser (202, 302, 402, 502) est installé sur la colonne de travail (332, 532),
    dans lequel la colonne de travail (332, 532) est abaissée autour de l'équipement de fond de puits (330, 430, 530), et
    dans lequel, lors de l'abaissement de la colonne de travail (332, 532) à une position dans laquelle l'outil laser (202, 302, 402, 502) est situé à proximité d'une obstruction de l'équipement de fond de puits, l'outil laser (202, 302, 402, 502) émet le faisceau laser collimaté en forme d'anneau (216, 316, 416, 517) de manière à dégager un espace annulaire (340, 440, 540) entre l'équipement de fond de puits (330, 430, 530) et une paroi du puits (338, 438, 538) afin de libérer l'équipement de fond de puits (330, 430, 530).
  2. Système laser selon la revendication 1,
    dans lequel le faisceau laser collimaté en forme d'anneau (216, 316, 416, 517) peut être positionné pour couper l'équipement de fond de puits (330, 430, 530).
  3. Système laser selon la revendication 1 ou 2,
    dans lequel l'outil laser comprend, en outre :
    une fibre optique ;
    un boîtier de tête laser (204) ;
    une lentille de couverture (212) ;
    une première lentille (208) ; et
    une seconde lentille (210),
    dans lequel un faisceau laser brut (214), émis par la fibre optique, traverse la première lentille (208) et la seconde lentille (210) pour générer un faisceau laser collimaté (216, 316, 416, 517), le boîtier de la tête laser (204) et la lentille de couverture (212) protégeant la première lentille (208) et la seconde lentille (210).
  4. Système laser selon l'une quelconque des revendications 1 à 3,
    dans lequel le moyen pour générer le faisceau laser collimaté en forme d'anneau (216, 316, 416, 517) comprend, en outre :
    la première lentille (208) qui est une lentille conique d'un angle interne particulier et d'un rapport d'aspect particulier ; et
    la seconde lentille (210) qui est la lentille conique de l'angle interne particulier et du rapport d'aspect particulier,
    dans lequel le faisceau laser brut (214), passant à travers la première lentille (208), produit un faisceau en forme d'anneau divergent et le faisceau en forme d'anneau divergent, passant à travers la seconde lentille (210), produit le faisceau laser collimaté en forme d'anneau (216, 316, 416, 517).
  5. Système laser selon l'une quelconque des revendications 1 à 4,
    dans lequel l'angle interne particulier et le rapport d'aspect particulier déterminent le diamètre intérieur (226) du faisceau laser collimaté en forme d'anneau, le diamètre extérieur (228) du faisceau laser collimaté en forme d'anneau et une excentricité du faisceau laser collimaté en forme d'anneau.
  6. Système laser selon l'une quelconque des revendications 1 à 5,
    dans lequel la colonne de travail est un outil de récupération (446) qui s'accroche à l'équipement de fond de puits (330, 430, 530) à extraire du puits de forage (102, 336, 436, 536).
  7. Procédé d'utilisation d'un système laser dans un puits de forage (102, 336, 436, 536) pour libérer un équipement de fond de puits (330, 430, 530) utilisé dans une opération de forage, caractérisé en ce qu'il comprend :
    l'installation d'un outil laser (202, 302, 402, 502), l'outil laser comprenant des moyens pour générer un faisceau laser collimaté en forme d'anneau (216, 316, 416, 517), sur une colonne de travail (332, 532) ;
    dans lequel l'outil laser (202, 302, 402, 502) et la colonne de travail (332, 532) présentent un diamètre intérieur supérieur au diamètre extérieur de l'équipement de fond de puits ;
    l'abaissement de la colonne de travail (332, 532) et de l'outil laser (202, 302, 402, 502) par-dessus l'équipement de fond de puits (330, 430, 530) jusqu'à une position située à proximité d'une obstruction de l'équipement de fond de puits ;
    la génération et l'émission du faisceau laser collimaté en forme d'anneau (216, 316, 416, 517) dans un espace annulaire (340, 440, 540) entre l'équipement de fond de puits (330, 430, 530) et une paroi du puits (338, 438, 538) de manière à dégager l'obstruction ; et
    l'extraction de la colonne de travail (332, 532) et de l'outil laser (202, 302, 402, 502) hors du puits de forage (102, 336, 436, 536).
  8. Procédé selon la revendication 7,
    dans lequel le faisceau laser collimaté en forme d'anneau (216, 316, 416, 517) peut être positionné pour couper l'équipement de fond de puits (330, 430, 530).
  9. Procédé selon la revendication 7 ou 8,
    dans lequel l'outil laser comprend, en outre :
    une fibre optique ;
    un boîtier de tête laser (204) ;
    une lentille de couverture (212) ;
    une première lentille (208) ; et
    une seconde lentille (210),
    dans lequel un faisceau laser brut (214), émis par la fibre optique, traverse la première lentille (208) et la seconde lentille (210) pour générer un faisceau laser collimaté (216, 316, 416, 517), le boîtier de la tête laser (204) protégeant, avec la lentille de couverture (212), la première lentille (208) et la seconde lentille (210).
  10. Procédé selon l'une quelconque des revendications 7 à 9,
    dans lequel le moyen de générer le faisceau laser collimaté en forme d'anneau (216, 316, 416, 517) comprend, en outre :
    la première lentille (208) qui est une lentille conique d'un angle interne particulier et d'un rapport d'aspect particulier ; et
    la seconde lentille (210) qui est la lentille conique de l'angle interne particulier et du rapport d'aspect particulier,
    dans lequel le faisceau laser brut (214), traversant la première lentille (208), produit un faisceau en forme d'anneau divergent et le faisceau en forme d'anneau divergent, traversant la seconde lentille (210), produit un faisceau laser collimaté en forme d'anneau (216, 316, 416, 517).
  11. Procédé selon l'une quelconque des revendications 7 à 10,
    dans lequel l'angle interne particulier et le rapport d'aspect particulier déterminent le diamètre intérieur (226) du faisceau laser collimaté en forme d'anneau, le diamètre extérieur (228) du faisceau laser collimaté en forme d'anneau et une excentricité du faisceau laser collimaté en forme d'anneau.
  12. Procédé selon l'une quelconque des revendications 7 à 11,
    dans lequel la colonne de travail est un outil de récupération (446) et le procédé comprend, en outre :
    l'accrochage de l'outil de récupération (446) à l'équipement de fond de puits (330, 430, 530) ; et
    l'extraction de l'outil de récupération (446), de l'outil laser (202, 302, 402, 502) et de l'équipement de fond de puits (330, 430, 530) hors du puits de forage (102, 336, 436, 536).
EP22709894.4A 2021-02-23 2022-02-23 Outils laser de fonds de puits et procédés Active EP4298315B1 (fr)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US17/182,568 US11905778B2 (en) 2021-02-23 2021-02-23 Downhole laser tool and methods
PCT/US2022/017525 WO2022182762A1 (fr) 2021-02-23 2022-02-23 Outil laser de fond de trou et procédés

Publications (2)

Publication Number Publication Date
EP4298315A1 EP4298315A1 (fr) 2024-01-03
EP4298315B1 true EP4298315B1 (fr) 2024-11-20

Family

ID=80735620

Family Applications (1)

Application Number Title Priority Date Filing Date
EP22709894.4A Active EP4298315B1 (fr) 2021-02-23 2022-02-23 Outils laser de fonds de puits et procédés

Country Status (4)

Country Link
US (1) US11905778B2 (fr)
EP (1) EP4298315B1 (fr)
CN (1) CN116888342A (fr)
WO (1) WO2022182762A1 (fr)

Families Citing this family (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20250034982A1 (en) * 2023-07-25 2025-01-30 Saudi Arabian Oil Company Trimming attachment tool and methods

Family Cites Families (12)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3871485A (en) 1973-11-02 1975-03-18 Sun Oil Co Pennsylvania Laser beam drill
US6755262B2 (en) 2002-01-11 2004-06-29 Gas Technology Institute Downhole lens assembly for use with high power lasers for earth boring
US6888097B2 (en) 2003-06-23 2005-05-03 Gas Technology Institute Fiber optics laser perforation tool
US9664012B2 (en) 2008-08-20 2017-05-30 Foro Energy, Inc. High power laser decomissioning of multistring and damaged wells
US8826973B2 (en) 2008-08-20 2014-09-09 Foro Energy, Inc. Method and system for advancement of a borehole using a high power laser
US10301912B2 (en) * 2008-08-20 2019-05-28 Foro Energy, Inc. High power laser flow assurance systems, tools and methods
WO2014031116A1 (fr) 2012-08-22 2014-02-27 Halliburton Energy Services, Inc. Libération de conduite bloquée dans un puits souterrain
CN203081295U (zh) 2012-12-28 2013-07-24 中国石油化工股份有限公司 一种井下激光辅助破岩的钻具
CN203334954U (zh) 2013-07-19 2013-12-11 东北石油大学 一种具有激光钻头的钻井装置
US9926758B1 (en) 2016-11-29 2018-03-27 Chevron U.S.A. Inc. Systems and methods for removing components of a subsea well
WO2019117871A1 (fr) 2017-12-12 2019-06-20 Foro Energy, Inc. Procédés et systèmes pour la réalisation de perçage détourage au laser
WO2019117868A1 (fr) 2017-12-12 2019-06-20 Foro Energy, Inc. Procédés de forage et de distribution de motifs de tir de faisceaux laser

Also Published As

Publication number Publication date
EP4298315A1 (fr) 2024-01-03
US20220268121A1 (en) 2022-08-25
CN116888342A (zh) 2023-10-13
WO2022182762A1 (fr) 2022-09-01
US11905778B2 (en) 2024-02-20

Similar Documents

Publication Publication Date Title
CN111989460B (zh) 用于优化钻探操作中的穿透速率的系统和方法
US10370920B2 (en) Wellbore intervention tool for penetrating obstructions in a wellbore
US20110139510A1 (en) Apparatus and Method for Reaming a Wellbore During the Installation of a Tubular String
US20190316444A1 (en) Coiled Tubing Assembly
US11933174B2 (en) Modified whipstock design integrating cleanout and setting mechanisms
EP4298315B1 (fr) Outils laser de fonds de puits et procédés
CN1052292C (zh) 在地下岩层中开槽的切割装置
US11624252B1 (en) Adjustable mill
US6401821B1 (en) Method and apparatus involving an integrated or otherwise combined exit guide and section mill for sidetracking or directional drilling from existing wellbores
Tessari et al. Casing Drilling–A revolutionary approach to reducing well costs
US12091925B2 (en) Fishing welding tool
RU2826033C2 (ru) Скважинная лазерная система и способ ее эксплуатации
US20230366284A1 (en) Stuck packer miller and external retrieval tool
US11643879B2 (en) Nested drill bit assembly for drilling with casing
US10557318B2 (en) Earth-boring tools having multiple gage pad lengths and related methods
US11725470B1 (en) Inverted tapered overshot
US20230304369A1 (en) Method and system for multilateral quick access in oil and gas industry
US11993995B2 (en) Tubular cutting and fishing tool
US12158052B2 (en) Flow back option plug assembly
US20240328272A1 (en) Rotating overshot guide
US12188319B2 (en) Sidetracking operation via laser cutting
GB2305953A (en) Selective core sampling after logging

Legal Events

Date Code Title Description
STAA Information on the status of an ep patent application or granted ep patent

Free format text: STATUS: UNKNOWN

STAA Information on the status of an ep patent application or granted ep patent

Free format text: STATUS: THE INTERNATIONAL PUBLICATION HAS BEEN MADE

PUAI Public reference made under article 153(3) epc to a published international application that has entered the european phase

Free format text: ORIGINAL CODE: 0009012

STAA Information on the status of an ep patent application or granted ep patent

Free format text: STATUS: REQUEST FOR EXAMINATION WAS MADE

17P Request for examination filed

Effective date: 20230920

AK Designated contracting states

Kind code of ref document: A1

Designated state(s): AL AT BE BG CH CY CZ DE DK EE ES FI FR GB GR HR HU IE IS IT LI LT LU LV MC MK MT NL NO PL PT RO RS SE SI SK SM TR

P01 Opt-out of the competence of the unified patent court (upc) registered

Effective date: 20240112

DAV Request for validation of the european patent (deleted)
DAX Request for extension of the european patent (deleted)
GRAP Despatch of communication of intention to grant a patent

Free format text: ORIGINAL CODE: EPIDOSNIGR1

STAA Information on the status of an ep patent application or granted ep patent

Free format text: STATUS: GRANT OF PATENT IS INTENDED

INTG Intention to grant announced

Effective date: 20240619

GRAS Grant fee paid

Free format text: ORIGINAL CODE: EPIDOSNIGR3

GRAA (expected) grant

Free format text: ORIGINAL CODE: 0009210

STAA Information on the status of an ep patent application or granted ep patent

Free format text: STATUS: THE PATENT HAS BEEN GRANTED

AK Designated contracting states

Kind code of ref document: B1

Designated state(s): AL AT BE BG CH CY CZ DE DK EE ES FI FR GB GR HR HU IE IS IT LI LT LU LV MC MK MT NL NO PL PT RO RS SE SI SK SM TR

REG Reference to a national code

Ref country code: GB

Ref legal event code: FG4D

REG Reference to a national code

Ref country code: CH

Ref legal event code: EP

REG Reference to a national code

Ref country code: DE

Ref legal event code: R096

Ref document number: 602022007959

Country of ref document: DE

REG Reference to a national code

Ref country code: IE

Ref legal event code: FG4D